Saes Z 020

 

Engineering Standard

 

SAES-Z-003

28 August 2013

Pipelines Leak Detection Systems Document Responsibility: Process Control Standards Comm Committee ittee

Saudi Aramco Desktop Standards  Table of Contents  1

Scope.............................................................  2  Scope............................................................. 

2

Conflicts and Deviations............................. Deviations................................. ....  2 

3

References..................................................... 2  References..................................................... 

4

Terms and Definitions..................... Definitions.................................... ............... 4 

5

PLDS Requirements......................... Requirements....................................... ..............  5 

6

Pipeline Leak Detection System Type Selection................................. Selection.................................  10  10 

7

Testing..........................................................  12  Testing.......................................................... 12 

 Appendix A - Incident Level and Pipeline Leak Detection Requirements………... 13  13 

Previous Issue: 22 July 2012 Next Planned Update: 22 July 2017 Revised paragraphs are indicated in the right margin Primary contact: Al-Anezi, Turki Khalifa on +966-3-8801835 Copyright©Saudi Aramco 2013. All rights reserved. 

Page 1 of 13

 

Document Responsibility: Process Control Standards Committee Issue Date: 28 August 2013  Next Planned Update: 22 July 2017

1

SAES-Z-003 Pipelines Leak Detection Systems

Scope This Standard defines the minimum mandatory requirements governing the scoping, design, installation, performance and online testing of Pipeline Leak Detection System (PLDS). This standard applies to new liquid and gas hydrocarbon pipelines, interconnecting  pipelines  between plants , excluding flow lines, trunk lines, test lines, and in plant  piping. Risk assessment shall be conducted to quantify the risk and justifi justification cation to  provide PLDS for each type of pipeline. “

2

”

Conflicts and Deviations 2.1

Any conflicts between this standard and other applicable Saudi Aramco Engineering Standards (SAESs), Materials System Specifications S pecifications (SAMSSs), Standard Drawings (SASDs), or industry standards, codes, and forms shall be resolved in writing by the Company or Buyer Representative through the Manager, Process & Control Systems Department (P&CSD) of Saudi Aramco, Dhahran.

2.2

3

Direct all requests to deviate from this standard in writing to the Company or Buyer Representative, who shall follow internal company procedure p rocedure  SAEP-302  SAEP-302  and forward such requests to the Manager, Process Proces s & Control Systems Department (P&CSD) Saudi Aramco, Dhahran.

References The selection of material and equipment, and the design, construction, maintenance, and repair of equipment and facilities covered by this standard shall comply compl y with the latest edition of the references listed below, unless otherwise noted. 3.1

Saudi Aramco References Saudi Aramco Engineering Procedure SAEP-302   SAEP-302

 Instructions for Obtaining a Waiver of a Mandatory Saudi Aramco Engineering Requirement

Saudi Aramco Engineering Standards SAES-A-102 SAES-A-102  

 Air Pollutant Emission Source Control

SAES-B-064   SAES-B-064

Onshore and Near shore Pipeline Safety

SAES-J-002 SAES-J-002  

Technically Acceptable Instruments

Page 2 of 13

 

Document Responsibility: Process Control Standards Committee Issue Date: 28 August 2013  Next Planned Update: 22 July 2017

SAES-Z-003 Pipelines Leak Detection Systems

SAES-J-003   SAES-J-003

 Basic Design Criteria

SAES-J-100   SAES-J-100

 Process Flow Metering

SAES-J-200   SAES-J-200

 Pressure

SAES-J-400 SAES-J-400   SAES-J-601  SAES-J-601 

Temperature  Emergency Shutdown and Isolation Systems

SAES-J-902 SAES-J-902  

 Electrical Systems for Instrumentation Instrumentation

SAES-T-624   SAES-T-624

Telecommunications outside Plant -Fiber Optics

SAES-T-911   SAES-T-911

Telecommunication Conduit System Design

SAES-T-928 SAES-T-928  

Telecommunications -OSP Buried Plant

SAES-Z-002   SAES-Z-002

Technically Accepted Process Automation Systems

Saudi Aramco Materials System Specifications 23-SAMSS-030 23-SAMSS-030  

 Remote Terminal Units

34-SAMSS-820   34-SAMSS-820

 Instrument Control Cabinet-Indoor

34-SAMSS-821 34-SAMSS-821  

 Instrument Control Cabinet-Outdoor

Saudi Aramco Inspection Requirements  Form  175-343600   Form 175-343600 

 Inspection & Testing Requirements, Pipeline Leak  Detection System (PLDS)

General Instruction GI-0002.401 GI-0002.401   3.2

 Inland Oil Spill Response

Industry Codes and Standards American Petroleum Institute  API PUBL 1130

Computational Pipeline Monitoring

 API PUBL 1149

Pipeline Variable Uncertainties & their Effect on  Leak Detectability

 ISO 5168 as part of the sensitivity study requirements Environmental Protection Agency  EPA530/UST-90/010

Standard Test Procedure to Evaluating Pipeline  Leak Detection Method: Pipeline Leak Detection System

Page 3 of 13

 

Document Responsibility: Process Control Standards Committee Issue Date: 28 August 2013  Next Planned Update: 22 July 2017

4

SAES-Z-003 Pipelines Leak Detection Systems

Terms and Definitions This section contains definitions for acronyms, abbreviations, classes as they are used in this document. 4.1

4.2

Acronyms and Abbreviations API

American Petroleum Institute

DCS

Distributed Control System

EPA

Environmental Protection Agency

G

Sweet Gas

GS

Sour Gas

ISA

The International Society of Automation

L

Sweet liquid

LS

Sour Liquid

LV

Volatile Sweet Liquids

LVS

Volatile Sour Liquids

PLDS

Pipeline Leak Detection System

PP

Project Proposal

RER

Rupture Exposure Radius

SCADA

Supervisory Control and Data Acquisition

Class Definition Below are location class definitions, for treatment of location classes: Class 1:

Class 1 locations are undeveloped areas within the RER for which the population density index for any 1 kilometer segment is 10 or less.

Class 2:

Class 2 locations are areas within the RER for which the population density index is 11 through 30 or pipeline sections adjacent or crossing primary or secondary highways as defined by b y the Saudi Arab Government Ministry of Transport (see clarifications below). Location Class 2 shall extend 500 meters or the RER distance, whichever is less, from the edge of the highway highwa y right-of-way. The portion of subsea pipelines located between Lowest Astronomical Tide (LAT) and points 0.4 kilometer on the seaward side of the LAT-line shall be designated for location Class 2. Page 4 of 13

 

Document Responsibility: Process Control Standards Committee Issue Date: 28 August 2013  Next Planned Update: 22 July 2017

SAES-Z-003 Pipelines Leak Detection Systems

Location Class 2 shall be the minimum used for the portion of these  pipelines located between LAT-line and the onshore anchor.

5

Class 3:

Class 3 locations are areas within the RER for which the population density index is more than 30.

Class 4:

Class 4 locations are areas within the RER in which a school, hospital, hotel, prison, or shopping mall or similar retail complex, or wedding hall is located, as well as any an y Class 3 areas which include  buildings of more than four occupied floors.

PLDS Requirements 5.1

General 5.1.1

Pipelines Leak Leak Detection Systems shall detect leaks if and when they occur, estimate the magnitude and location of a leak and generate operator alert/alarms. alert/alarms. Pipeline Leak Detection System shall be selected selected  based on one of the following: 5.1.1.1

For onshore/midstream pipelines, the selected leak detection system shall meet the minimum performance requirement as stated in this specification document as stated in Tables 9 through 12.

5.1.1.2

Leak performance study shall be considered for all type of  pipelines on as needed basis. For pipeline network or pipelines that are not classified by SAES-B-064 SAES-B-064,, indicate the use of risk assessment in compliance with the end user  proponent  risk management policies “

”

A leak performance study that considers risk assessment shall  be conducted that determines the impact of the pipeline (s) leak or rupture on the neighboring community, communit y, highway traffic, and environment. Study shall consider minimum response time and the amount of product expected to be released until total isolation is achieved. achieved. This study determines required leak detection system performance criteria and performance considerations for the pipeline or pipeline network under und er consideration. Tables 9 through 12 outline the minimum  performance requirements. 5.1.2

Technology selections shall be considered for each specific pipeline application to meet this standard criteria and suit a given pipeline Page 5 of 13

 

Document Responsibility: Process Control Standards Committee Issue Date: 28 August 2013  Next Planned Update: 22 July 2017

SAES-Z-003 Pipelines Leak Detection Systems

configuration. The selection of technology shall be approved by P&CSD and Pipelines for each application during the Project Proposal phase and take into consideration communication infrastructure, monitoring system and field instrumentation. Also, the pipeline operating parameters (pressure, temp., density, flow) should be considered fortype. selecting the technology besides the pipeline configuration and fluid

5.2

5.1.3

The operating requirements of each leak detection system, including instrumentation accuracy, repeatability and measurement precision, communication reliability and sampling frequency should determine whether the leak detection system would share or use compatible instrumentations of the specific pipelines monitoring system.

5.1.4

The design shall utilize to to the maximum extent possible the existing field equipment and communication infrastructure without degrading the leak detection system's ability to recognize potential or actual leak as a result of inadequate data acquisition frequency or bad data quality.

5.1.5

Environmental impact should be considered for selecting PLDS for cross-country pipelines. pipelines. The environmental impact analysis shall include air, land, water, energy, and noise level.

Performance Criteria for Liquid Pipeline Leak Detection performance shall consider overall leak detection components such as field instruments, communication devices and media, and PLDS internal components. Pipeline Leak Detection performance shall consider  pipeline dimensions, liquid type, and operating conditions. Selecting proper type of Pipeline Leak Detection System shall be governed by the following performance criteria: 5.2.1

Sensitivity : Is a composite measure of the size of the leak (in terms of spilled volume, usually in BBL) that the system s ystem is capable of detecting and the time (usually in minutes) required for the system to generate an alarm in the event that a leak of that spilled volume  should occur. “

”

Table 1 1  defines the sensitivity requirements for PLDS selection for liquid  pipelines. The requirements are divided into three sensitivity levels, High, Medium, and Low. Low. Each is further further divided into three three operating  pressure levels which is a major factor in determining the leak volume. Based on this classification, Pipeline Leak Detection sensitivity requirements for liquid pipelines are as shown in the table below. 

Page 6 of 13

 

Document Responsibility: Process Control Standards Committee Issue Date: 28 August 2013  Next Planned Update: 22 July 2017

SAES-Z-003 Pipelines Leak Detection Systems

Table 1  – Sensitivity Sensitivity Requirements for Liquid Level High

Medium

Low

Description 18 18 18 18 18 18

Operating Pressure Range

mm (0.75 inch) of leak size within 3 minutes mm (0.75 inch) of leak size within 5 minutes mm (0.75 inch) of leak size within 7 minutes mm (0.75 inch) of leak size within 10 minutes mm (0.75 inch) of leak size within 12 minutes mm (0.75 inch) of leak size within 15 minutes

Greater than 600 psig 300psig-600psig Below 300 psig Greater than 600 psig 300psig-600psig Below 300 psig

18 mm (0.75 inch) of leak size with 1 hour 18 mm (0.75 inch) of leak size with 1 and a half hour 18 mm (0.75 inch) of leak size with 2 hours

Greater than 600 psig 300psig-600psig Below 300 psig

5.2.2

measure of the Pipeline Leak Detection System ability Reliability : Is a measure to continue detecting and locating leaks without generating false alarms, while operating within the envelop established by the Pipeline Leak Detection System design. It is measured as false alarms per year. Table 2 defines the minimum levels of o f reliability for PLDS selection. Table 2  –  Reliability   Reliability Level High Medium Low

5.2.3

Description Shall not exceed one false alarm per year for the High Sensitivity level stated in  in Table 1 1..  Shall not exceed three false alarms per year for the 1..  Medium Sensitivity level stated in  in Table 1 Shall not exceed five false alarms per year for the Low Sensitivity level stated in  in Table 1 1.. 

Accuracy:  Is the validity of the estimated leak flow rate, total volume lost, and leak location within an acceptable degree of tolerance.

Table 3 defines the minimum levels of accuracy for PLDS selection. Table 3  –  Accuracy  Accuracy Level High Medium Low

Description Shall not exceed ± 200 meters of actual leak location for the High Sensitivity level stated in  in Table 1. 1 .  Shall not exceed ± 1000 meters of actual leak location for 1..  the Medium Sensitivity level stated in  in  Table 1 Shall not exceed ± 2000 meters of actual leak location for the Low Sensitivity level stated in  in Table 1. 1.   Page 7 of 13

 

Document Responsibility: Process Control Standards Committee Issue Date: 28 August 2013  Next Planned Update: 22 July 2017

5.2.4

SAES-Z-003 Pipelines Leak Detection Systems

Robustness: Is a measure of the Pipeline Leak Detection System abi ability lity to continue to function and provide useful information, even under changing conditions of pipeline operation, or in conditions where data is

temporary lost or suspected. Table 4 defines the minimum levels of o f robustness for PLDS selection. Table 4  –  Robustness  Robustness Level High

Medium

Low

Description Loss of a field sensor/communication link will not degrade performance Loss of a field sensor/communication link may reduce accuracy and/or sensitivity of detecting 1  and/or 3. leaks by one level of  Table 1 Loss of a field sensor/communication link may cause failure to detect leaks

5.3

Performance Criteria for Gas Table 5  – Sensitivity Sensitivity Requirements for Gas

Level

High

Medium

Low

Description

Operating Pressure Range

18 mm (0.75 inch) of leak size within 3 minutes

Greater than 600 psig

18 mm (0.75 inch) of leak size within 5 minutes

300psig-600psig

18 mm (0.75 inch) of leak size within 7 minutes

Below 300 psig

18 mm (0.75 inch) of leak size within 10 minutes

Greater than 600 psig

18 mm (0.75 inch) of leak size within 12 minutes

300psig-600psig

18 mm (0.75 inch) of leak size within 15 minutes

Below 300 psig

18 mm (0.75 inch) of leak size with 1 hour

Greater than 600 psig

18 mm (0.75 inch) of leak size with 1 and a half hour

300psig-600psig

18 mm (0.75 inch) of leak size with 2 hours

Below 300 psig

5.3.1

measure of the Pipeline Leak Detection System System ability Reliability : Is a measure to continue detecting and locating leaks le aks without generating false alarms, while operating within the envelop established by the Pipeline Leak Detection System design. It is measured as false alarms per year. year. 6 defines the minimum levels of reliability for PLDS selection. Table 6 

Page 8 of 13

 

Document Responsibility: Process Control Standards Committee Issue Date: 28 August 2013  Next Planned Update: 22 July 2017

SAES-Z-003 Pipelines Leak Detection Systems

Table 6  –  Reliability   Reliability Level

Description

High

Shall not exceed one false alarm year for the High Sensitivity level stated in Table in  5 5..per  

Medium Low

5.3.2

Shall not exceed three false alarms per year for the 5..  Medium Sensitivity level stated in  in Table 5 Shall not exceed five false alarms per year for the Low Sensitivity level stated in  in Table 5 5.. 

Accuracy:  Is the validity of the estimated leak flow rate and leak location within an acceptable degree of tolerance.

Table 7 defines the minimum levels of accuracy for PLDS selection. Table 7  –  Accuracy  Accuracy Level

5.3.3

Description

High

Shall not exceed ± 750 meters of actual leak location for the High Sensitivity level stated in  in Table 5. 5 . 

Medium

Shall not exceed ± 1500 meters of actual leak location for 5..  the Medium Sensitivity level stated in  in Table 5

Low

Shall not exceed ± 2500 meters of actual leak location for the Low Sensitivity level stated in  in Table 5. 5.  

Robustness: Is a measure of the System ability to continue to function and provide useful information, even under changing conditions of  pipeline operation, or in conditions where data is temporary lost or suspected.

Table 8 defines the minimum levels of robustness for PLDS P LDS selection. Table 8  –  Robustness  Robustness Level High

Medium

Low

Description Loss of a field sensor/communication link will not degrade performance Loss of a field sensor/communication link may reduce accuracy and/or sensitivity of detecting leaks by one level of Table 5 and/or 7. Loss of a field sensor/communication link may cause failure to detect leaks

Page 9 of 13

 

Document Responsibility: Process Control Standards Committee Issue Date: 28 August 2013  Next Planned Update: 22 July 2017

6

SAES-Z-003 Pipelines Leak Detection Systems

Pipeline Leak Detection System Type Selection This standard does not require specific Pipeline Leak Detection technology or product; however, the standard sets the performance measure for pipelines applications. 6.1

6.2

The following pipelines applications are addressed by this standard: G

Sweet gas (treated gas, i.e., sale gas with specification A-120 (Hydrogen Sulfide, grains/100 SCF (grains/100 CM))

GS

Sour gas (gas concentration H2S >1% Hydrogen Sulfide)

L

Sweet liquid (stabilized crude or treated condensate 300 PPM Hydrogen Sulfide

LV

Volatile sweet liquids 300 ppm Hydrogen Sulfide)

Class Requirements through 12)  12) state the minimum performance measure The following tables (9 through requirements for each corresponding class of pipeline applications. Table 9  –  Location  Location Classes 1 Service

Performance Measure

G

GS

L

LS

LV

LVS

Reliability

Low

Low

Low

Low

Low

Low

Sensitivity

Low

Low

Low

Low

Low

Low

 Accuracy

Low

Low

Low

Low

Low

Low

Robustness

Low

Low

Low

Low

Low

Low

Table 10  –  Location  Location Classes 2 Service

Performance Measure

G

GS GS

L

LS

LV

LVS

Reliability

Low

Medium

Low

Medium

Low

Medium

Sensitivity

Low

Medium

Low

Medium

Low

Medium

 Accuracy

Low

Medium

Low

Medium

Low

Medium

Robustness

Low

Medium

Low

Medium

Low

Medium

Page 10 of 13

 

Document Responsibility: Process Control Standards Committee Issue Date: 28 August 2013  Next Planned Update: 22 July 2017

SAES-Z-003 Pipelines Leak Detection Systems

Table 11  –  Location  Location Classes 3 Service

Performance Measure

G

GS

L

LS

LV

LVS

Reliability

Medium

High

Medium

High

Medium

High

Sensitivity

Medium

High

Medium

High

Medium

High

 Accuracy

Medium

High

Medium

High

Medium

High

Robustness

Medium

High

Medium

High

Medium

High

Table 12  –  Location  Location Classes 4

6.3

6.4

Service

Performance Measure

G

GS

L

LS

LV

LVS

Reliability

High

High

Medium

High

Medium

High

Sensitivity

High

High

Medium

High

Medium

High

 Accuracy

High

High

Medium

High

Medium

High

Robustness

High

High

Medium

High

Medium

High

Leak Monitoring Package-Software Engine 6.3.1

Leak monitoring software shall provide continuous operator alert and logging functions for the pipelines including real time simulation capability for diagnostics

6.3.2

Leak monitoring software shall provide history archive of actual leak leak detected and suspected or filtered events.

6.3.3

Leak monitoring software shall provide report to indicate leak details with capability to print or display on the designated operator workstation. The system shall announce the location of the leak within time fame that does not exceed twice of the Pipeline Leak Detection time specified in  in Table 2. 2.  The report may include topographical locations coordinates, etc.

Field Instrumentation Selection Criteria The selection, application and installation of Pipeline Leak Detection field instrumentation shall meet the reliability and robustness measures for the  pipeline class. Conventional instruments such as pressure, temperature, etc., instruments ruments shall shall be shall meet requirements referenced in  in Section 3.1. 3.1.  Other inst selected based on selected PLDS recommendation. Page 11 of 13

 

Document Responsibility: Process Control Standards Committee Issue Date: 28 August 2013  Next Planned Update: 22 July 2017

6.5

SAES-Z-003 Pipelines Leak Detection Systems

Remote Terminal Units (RTU) The field devices may be dedicated for the application or shared with a DCS or SCADA. Selection of either approach will be determined by the application application  performance measures. This also may determine the use of dedicated communication media and operator interface subsystems.

7

Testing 7.1

The Leak Detection System shall be tested to comply with the followings:

  Performance measures determined by the leak detection d etection (risk assessment) study per Saudi Aramco FAT/SAT test doc



or,

  Approved international standard procedures (i.e., API, EPA), Proponent Proponen t test  procedures and requirements.



7.2

New PLDS project shall develop functional specification, FAT and SAT  procedures. The project shall consider commissioning the system through an actual product release. The project shall develop and obtain approval for for  product release procedure.

7.3

As a minimum, Pipeline Leak Detection System shall be periodically tested per Table 13. The tests shall demonstrate correct functionality of ffield ield instrumentations, communication and monitoring systems as per the validation test procedure. Table 13  –  Testing  Testing Intervals Service (by Proponent)

22 July 2012 28 August 2013

Performance Measure

G

GS

L

LS

LV

LVS

Class I

Annual

Annual

Annual

Annual

Annual

Annual

Class II

Annual

Annual

Annual

Annual

Annual

Annual

Class III

Six months

Six months

Six months

Six months

Six months

Six months

Class IV

Six months

Six months

Six months

Six months

Six months

Six months

Revision Summary Major revision. Editorial revision to Section 5.1.2 and replaced DBSP with Project Proposal.

Page 12 of 13

 

Document Responsibility: Process Control Standards Committee Issue Date: 28 August 2013  Next Planned Update: 22 July 2017

SAES-Z-003 Pipelines Leak Detection Systems

Appendix A - Incident Level and Pipeline Leak Detection Requirements

A.1

Background Pipeline Leak Detection sensitivity in pipelines is defined for liquid products by the American Petroleum Institute (API) in Recommended Practice 1130 entitled C omputa utationa tionall P Pii peline li ne M onito ni torr i ng ffo or L i quid ui ds - A API PI 113 1130/ 0/115 1155 5 , First Edition, September 2007. The Recommended Practice defines defines Pipeline Leak Detection sensitivity as a two-dimensional concept in term of a series of sensitivity curves  that  spilla illage ge volum lume,  which are dependent on spillage flow rate  and represent the  sp time  under different operating conditions. In turn, the spillage flow rate is also a factor of many parameters such as pipeline diameter, operating pressure, and the fluid type. API 1130/1155 covers only liquid pipelines leak detection criteria without mentioning gas pipeline leak detection criteria. “

”

“

”

“

“

“

”

”

”

It is the intention version of this specification document toacover leak detection criteria of forthis liquid as well as gas pipelines. Since gas is pressurized pressurized substance with varying volume under different pressure conditions, the industry ind ustry selected SCF (standard cubic foot) as the proper prop er measure for gas quantity, and da y) as the proper measure for gas flow MMSCFD (million standard cubic foot per day) rate. Therefore, this specification will will provide leak detection criter criteria ia based on detected spilled volume for liquid (oil, NGL, and other liquid products), and will  provide leak detection criteria based on MMSCFD (or percentage of it) for gas  products, taking into account pipeline dimensions and operating conditions. A.2

Incident Level and Leak Sensitivity Definition for Liquid The previous publication of this document made mad e the following definition:

The 18 mm (0.75 inch) leak size was driven using estimated pinhole to cause i nci ncide dent nt leve levels ls (M ( M ajor ajor,, Mod M ode er at ate e, and M i nor) . A s an an ex exam ample ple,, the lea leakk system system  sha  sh all be i ns nsttalle lled d to detect a le lea ak of of sp spill siz size e le less ss tha han n 10 1000 00 B B L (Mi ( Mi no norr lev level). The spill flow rate and the time shall not exceed the minor incident level spill quan uanti tity ty ( 1000 BB B B L withi within n 8 HR H R S) S).. T he time to sto stop p the le lea ak should be divided between mobilization time, repair time and leak detection instrument r esp esponse onse tim ti me.  

“ 

” 

This definition sets the Incident Level Minor   of 1000 barrels per 8 hours as the  basis for all other performance performance criter criteria. ia. It should should be noted noted that above definition definition applies only to liquid products since barrel is not a valid measurement unit for gas. “

”

Page 13 of 13